United States
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the quarterly period ended:
September 30, 2023
☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the transition period from _______________ to _______________
Commission
File No.
Name of Registrant, State of Incorporation, Address
of Principal Executive Offices, and Telephone No.
IRS Employer
Identification No.
000-49965
MGE Energy, Inc.
(a Wisconsin Corporation)
133 South Blair Street
Madison, Wisconsin 53788
(608) 252-7000 | mgeenergy.com
39-2040501
000-1125
Madison Gas and Electric Company
(608) 252-7000 | mge.com
39-0444025
Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days:
MGE Energy, Inc. Yes ☒ No ☐
Madison Gas and Electric Company Yes ☒ No ☐
Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files):
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer
Accelerated
Filer
Non-accelerated Filer
Smaller Reporting Company
Emerging Growth Company
☒
☐
If an emerging growth company, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
MGE Energy, Inc. ☐
Madison Gas and Electric Company ☐
Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act):
MGE Energy, Inc. Yes ☐ No ☒
Madison Gas and Electric Company Yes ☐ No ☒
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Trading symbol(s)
Name of each exchange on which registered
Common Stock, $1 Par Value Per Share
MGEE
The NASDAQ Stock Market
Number of Shares Outstanding of Each Class of Common Stock as of October 31, 2023
Common stock, $1.00 par value, 36,163,370 shares outstanding.
Common stock, $1.00 par value, 17,347,894 shares outstanding (all of which are owned beneficially and of record by MGE Energy, Inc.).
1
Table of Contents
PART I. FINANCIAL INFORMATION
3
Filing Format
Forward-Looking Statements
Where to Find More Information
Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report
4
Item 1. Financial Statements.
6
Consolidated Statements of Income (unaudited)
Consolidated Statements of Cash Flows (unaudited)
7
Consolidated Balance Sheets (unaudited)
8
Consolidated Statements of Common Equity (unaudited)
9
10
11
12
Consolidated Statements of Equity (unaudited)
13
MGE Energy, Inc., and Madison Gas and Electric Company - Notes to Consolidated Financial Statements (unaudited)
14
1. Summary of Significant Accounting Policies.
2. New Accounting Standards.
15
3. Investment in ATC and ATC Holdco.
4. Taxes.
16
5. Pension and Other Postretirement Plans.
17
6. Equity and Financing Arrangements.
7. Share-Based Compensation.
18
8. Commitments and Contingencies.
9. Rate Matters.
22
10. Derivative and Hedging Instruments.
23
11. Fair Value of Financial Instruments.
26
12. Joint Plant Construction Project Ownership.
29
13. Revenue.
14. Segment Information.
30
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.
31
Item 3. Quantitative and Qualitative Disclosures About Market Risk.
50
Item 4. Controls and Procedures.
PART II. OTHER INFORMATION.
51
Item 1. Legal Proceedings.
Item 1A. Risk Factors.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.
Item 3. Defaults Upon Senior Securities.
Item 4. Mine Safety Disclosures.
Item 5. Other Information.
Item 6. Exhibits.
52
Signatures - MGE Energy, Inc.
53
Signatures - Madison Gas and Electric Company
54
2
PART I. FINANCIAL INFORMATION.
This combined Form 10-Q is being filed separately by MGE Energy, Inc. (MGE Energy) and Madison Gas and Electric Company (MGE). MGE is a wholly owned subsidiary of MGE Energy and represents a majority of its assets, liabilities, revenues, expenses, and operations. Thus, all information contained in this report relates to, and is filed by, MGE Energy. Information that is specifically identified in this report as relating solely to MGE Energy, such as its financial statements and information relating to its nonregulated business, does not relate to, and is not filed by, MGE. MGE makes no representation as to that information. The terms "we" and "our," as used in this report, refer to MGE Energy and its consolidated subsidiaries, unless otherwise indicated.
This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions—especially as they relate to economic conditions, future load growth, revenues, expenses, capital expenditures and rate recovery, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. Words such as "believe," "expect," "anticipate," "estimate," "could," "should," "intend," "will," and other similar words, and words relating to goals, targets and projections, generally identify forward-looking statements. Both MGE Energy and MGE caution investors that these forward-looking statements are subject to known and unknown risks and uncertainties that may cause actual results to differ materially from those projected, expressed, or implied.
The factors that could cause actual results to differ materially from the forward-looking statements made by a registrant include: (a) those factors discussed in the registrants' 2022 Annual Report on Form 10-K: Item 1A. Risk Factors, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, as updated by Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations in this report, and Item 8. Financial Statements and Supplementary Data – Note 16, as updated by Part I, Item 1. Financial Statements – Note 8 in this report, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.
Readers are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this report. MGE Energy and MGE undertake no obligation to release publicly any revision to these forward-looking statements to reflect events or circumstances after the date of this report, except as required by law.
We file annual reports on Form 10-K, quarterly reports on Form 10-Q and current reports on Form 8-K and other information with the SEC. The SEC maintains an internet site at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC. MGE Energy maintains a website at mgeenergy.com, and MGE maintains a website at mge.com. Copies of the reports and other information that we file with the SEC may be obtained from our websites free of charge. Information contained on MGE Energy's and MGE's websites shall not be deemed incorporated into, or to be a part of, this report.
Abbreviations, acronyms, and definitions used in the text and notes of this report are defined below.
MGE Energy and Subsidiaries:
CWDC
Central Wisconsin Development Corporation
MAGAEL
MAGAEL, LLC
MGE
MGE Energy
MGE Power
MGE Power, LLC
MGE Power Elm Road
MGE Power Elm Road, LLC
MGE Power West Campus
MGE Power West Campus, LLC
MGE Services
MGE Services, LLC
MGE State Energy Services
MGE State Energy Services, LLC
MGE Transco
MGE Transco Investment, LLC
MGEE Transco
MGEE Transco, LLC
North Mendota
North Mendota Energy & Technology Park, LLC
Other Defined Terms:
2017 Tax Act
Tax Cut and Jobs Act of 2017
2022 Annual Report on Form 10-K
MGE Energy's and MGE's Annual Report on Form 10-K for the year ended December 31, 2022
2021 Plan
MGE Energy's 2021 Long-Term Incentive Plan
AFUDC
Allowance for Funds Used During Construction
ATC
American Transmission Company LLC
ATC Holdco
ATC Holdco, LLC
Badger Hollow I
Badger Hollow I Solar Farm
Badger Hollow II
Badger Hollow II Solar Farm
Blount
Blount Station
BTA
Best technology available
CA
Certificate of Authority
CASAC
Clean Air Scientific Advisory Committee
CBP
U.S. Customs and Border Protection
CCR
Coal Combustion Residual
Columbia
Columbia Energy Center
cooling degree days (CDD)
Measure of the extent to which the average daily temperature is above 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide cooling
CSAPR
Cross-State Air Pollution Rule
D.C. Circuit
United States Court of Appeals for the District of Columbia Circuit
Darien
Darien Solar Energy Center
Dth
Dekatherms, a quantity measure for natural gas
EGU
Electric generating unit
ELG
Effluent Limitations Guidelines
Elm Road Units
Elm Road Generating Station
EPA
United States Environmental Protection Agency
FASB
Financial Accounting Standards Board
FERC
Federal Energy Regulatory Commission
FIP
Federal Implementation Plan
FTR
Financial Transmission Rights
GHG
Greenhouse gas
heating degree days (HDD)
Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
IRS
Internal Revenue Service
kWh
Kilowatt-hour, a measure of electric energy produced
MISO
Midcontinent Independent System Operator (a regional transmission organization)
MW
Megawatt, a measure of electric energy generating capacity
MWh
Megawatt-hour, a measure of electric energy produced
NAAQS
National Ambient Air Quality Standards
Nasdaq
The Nasdaq Stock Market
NOx
Nitrogen oxide
NSPS
New Source Performance Standards
Paris
Paris Solar and Battery Park
the Petition
Petition for Judicial Review of Agency Action
PGA
Purchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
PM
Particulate Matter
PPA
Purchased Power Agreement
PSCW
Public Service Commission of Wisconsin
ROE
Return on equity
SEC
Securities and Exchange Commission
SO2
Sulfur dioxide
Stock Plan
Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UFLPA
Uyghur Forced Labor Protection Act
USDOC
U.S. Department of Commerce
WCCF
West Campus Cogeneration Facility
WDNR
Wisconsin Department of Natural Resources
WEPCO
Wisconsin Electric Power Company, a subsidiary of WEC Energy Group, Inc.
West Riverside
West Riverside Energy Center in Beloit, Wisconsin
working capital
Current assets less current liabilities
WPDES
Wisconsin Pollutant Discharge Elimination System
WPL
Wisconsin Power and Light Company, a subsidiary of Alliant Energy Corporation
WRO
Withhold Release Order
XBRL
eXtensible Business Reporting Language
5
(In thousands, except per share amounts)
Three Months Ended
Nine Months Ended
September 30,
2023
2022
Operating Revenues:
Electric revenues
$
139,104
133,090
378,102
355,381
Gas revenues
21,424
30,310
147,677
169,305
Total Operating Revenues
160,528
163,400
525,779
524,686
Operating Expenses:
Fuel for electric generation
19,712
21,045
47,118
48,410
Purchased power
7,021
9,593
28,252
35,757
Cost of gas sold
5,160
14,523
80,296
100,638
Other operations and maintenance
53,997
49,194
156,004
150,714
Depreciation and amortization
25,241
21,447
74,971
63,780
Other general taxes
5,605
5,111
16,922
15,579
Total Operating Expenses
116,736
120,913
403,563
414,878
Operating Income
43,792
42,487
122,216
109,808
Other income, net
10,549
6,068
20,841
20,736
Interest expense, net
(7,654
)
(6,652
(22,901
(19,686
Income before income taxes
46,687
41,903
120,156
110,858
Income tax provision
(8,830
(8,183
(22,540
(20,957
Net Income
37,857
33,720
97,616
89,901
Earnings Per Share of Common Stock
Basic
1.05
0.93
2.70
2.49
Diluted
Dividends per share of common stock
0.428
0.408
1.243
1.183
Weighted Average Shares Outstanding
36,163
36,189
36,176
36,185
36,174
The accompanying notes are an integral part of the above unaudited consolidated financial statements.
(In thousands)
Operating Activities:
Net income
Items not affecting cash:
Deferred income taxes
16,326
18,021
Provision for doubtful receivables
1,323
Employee benefit plan cost (credit)
(2,976
(6,087
Equity earnings in investments
(7,930
(6,626
Other items
(2,502
(2,821
Changes in working capital items:
Decrease (increase) in current assets
33,976
(5,992
(Decrease) increase in accounts payable
(16,586
66
Decrease in other current liabilities
(3,714
(5,897
Dividends from investments
6,305
5,964
Cash contributions to pension and other postretirement plans
(5,290
(5,095
Other noncurrent items, net
2,519
(2,255
Cash Provided by Operating Activities
194,038
144,282
Investing Activities:
Capital expenditures
(150,298
(133,409
Capital contributions to investments
(5,986
(3,938
Other
(206
128
Cash Used for Investing Activities
(156,490
(137,219
Financing Activities:
Cash dividends paid on common stock
(44,933
(42,763
Repayments of long-term debt
(53,048
(3,655
Issuance of long-term debt
109,300
—
(Repayments of) proceeds from short-term debt
(48,500
34,500
(2,128
(745
Cash Used for Financing Activities
(39,309
(12,663
Change in cash, cash equivalents, and restricted cash
(1,761
(5,600
Cash, cash equivalents, and restricted cash at beginning of period
17,968
18,835
Cash, cash equivalents, and restricted cash at end of period
16,207
13,235
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures
17,716
11,218
December 31,
ASSETS
Current Assets:
Cash and cash equivalents
11,269
11,604
Accounts receivable, less reserves of $6,082 and $7,050, respectively
43,819
55,407
Other accounts receivable, less reserves of $1,490 and $1,323, respectively
17,270
11,418
Unbilled revenues
24,687
43,086
Materials and supplies, at average cost
35,329
33,465
Fuel for electric generation, at average cost
9,492
7,962
Stored natural gas, at average cost
27,595
32,848
Prepaid taxes
13,856
19,132
Regulatory assets - current
18,308
9,541
Other current assets
14,786
19,017
Total Current Assets
216,411
243,480
Regulatory assets
96,764
103,900
Pension benefit asset
74,087
68,872
Other deferred assets and other
21,485
24,365
Property, Plant, and Equipment:
Property, plant, and equipment, net
1,902,032
1,865,352
Construction work in progress
168,504
105,748
Total Property, Plant, and Equipment
2,070,536
1,971,100
Investments
111,249
105,883
Total Assets
2,590,532
2,517,600
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year
5,112
54,314
Short-term debt
22,000
70,500
Accounts payable
53,593
59,334
Accrued interest and taxes
7,368
7,868
Accrued payroll related items
13,155
13,064
Regulatory liabilities - current
13,462
11,925
Other current liabilities
8,148
8,057
Total Current Liabilities
122,838
225,062
Other Credits:
271,453
252,190
Investment tax credit - deferred
47,369
48,735
Regulatory liabilities
155,026
156,988
Accrued pension and other postretirement benefits
54,531
53,607
Finance lease liabilities
17,932
17,108
Other deferred liabilities and other
96,102
96,990
Total Other Credits
642,413
625,618
Capitalization:
Common shareholders' equity
1,135,253
1,081,674
Long-term debt
690,028
585,246
Total Capitalization
1,825,281
1,666,920
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization
Accumulated
Additional
Common Stock
Paid-in
Retained
Comprehensive
Shares
Value
Capital
Earnings
Income/(Loss)
Total
Three Months Ended September 30, 2022
Beginning Balance
395,338
624,556
1,056,057
Common stock dividends declared ($0.408 per share)
(14,736
Equity-based compensation plans and other
159
Ending Balance - September 30, 2022
395,497
643,540
1,075,200
Three Months Ended September 30, 2023
396,281
680,140
1,112,584
Common stock dividends declared ($0.428 per share)
(15,460
272
Ending Balance - September 30, 2023
396,553
702,537
Nine Months Ended September 30, 2022
394,903
596,402
1,027,468
Common stock dividends declared ($1.183 per share)
594
Nine Months Ended September 30, 2023
395,657
649,854
Common stock dividends declared ($1.243 per share)
896
53,847
48,989
155,251
150,024
5,106
15,573
116,586
120,703
402,810
414,182
43,942
42,697
122,969
110,504
7,824
4,430
13,985
12,467
(7,721
(6,662
(23,056
(19,709
44,045
40,465
113,898
103,262
(8,093
(7,664
(20,696
(18,781
35,952
32,801
93,202
84,481
Less: Net Income Attributable to Noncontrolling Interest, net of tax
(5,487
(5,603
(16,382
(15,947
Net Income Attributable to MGE
30,465
27,198
76,820
68,534
15,218
17,706
(2,604
(636
33,076
(7,238
(16,583
64
(1,809
(3,706
1,840
(2,806
190,368
141,786
(1,338
(680
(151,636
(134,089
Cash dividends paid to parent by MGE
(30,000
(21,000
Distributions to parent from noncontrolling interest
(17,250
(17,500
(41,626
(8,400
(2,894
(703
10,500
7,798
7,606
7,095
2,668
4,136
17,268
11,416
14,055
18,467
15,284
19,479
208,505
235,807
21,611
24,817
1,902,060
1,865,380
2,070,564
1,971,128
83
115
2,471,614
2,404,639
53,578
59,317
7,323
7,912
6,062
122,778
223,094
237,414
219,258
98,198
98,217
610,470
593,913
Common shareholder's equity
901,043
854,223
Noncontrolling interest
147,295
148,163
Total Equity
1,048,338
1,002,386
1,738,366
1,587,632
Non-
Controlling
Interest
Beginning balance
17,348
252,917
562,878
145,681
978,824
5,603
(9,000
(4,250
581,076
147,034
998,375
609,313
148,808
1,028,386
5,487
(7,000
630,778
533,542
148,587
952,394
15,947
583,958
16,382
MGE Energy, Inc., and Madison Gas and Electric Company
Notes to Consolidated Financial Statements (unaudited)
This report is a combined report of MGE Energy and MGE. References in this report to "MGE Energy" are to MGE Energy, Inc. and its subsidiaries. References in this report to "MGE" are to Madison Gas and Electric Company.
MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative accounting guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 3 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2022 Annual Report on Form 10-K (the 2022 Annual Report on Form 10-K).
The accompanying consolidated financial statements as of September 30, 2023, and during the three and nine months ended, are unaudited but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in the 2022 Annual Report on Form 10-K but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 57 through 107 of the 2022 Annual Report on Form 10-K.
The following table presents the components of total cash, cash equivalents, and restricted cash on the consolidated balance sheets.
Restricted cash
645
867
Receivable - margin account
4,293
5,497
Cash, cash equivalents, and restricted cash
Cash Equivalents
All highly liquid investments purchased with an original maturity of three months or less are considered to be cash equivalents.
Restricted Cash
MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include cash held by trustees for certain employee benefits and cash deposits held by third parties. These are included in "Other current assets" on the consolidated balance sheets.
Receivable – Margin Account
Cash amounts held by counterparties as margin collateral for certain financial transactions are recorded as Receivable – margin account in "Other current assets" on the consolidated balance sheets. The costs being hedged are fuel for electric generation, purchased power, and cost of gas sold.
Columbia.
An asset that will be retired in the near future and substantially in advance of its previously expected retirement date is subject to abandonment accounting. In the second quarter of 2021, the operator of Columbia received approval from MISO to retire Columbia Units 1 and 2. The co-owners intend to retire Unit 1 and Unit 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of September 30, 2023, early retirement of Columbia was probable.
The net book value of our ownership share of this generating unit was $133.0 million as of September 30, 2023. This amount was classified as plant to be retired within "Property, plant, and equipment, net" on the consolidated balance sheets. Assets for Columbia Unit 1 and Unit 2 are currently included in rate base, and MGE continues to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW that include retirement dates of 2029 for both Units.
If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded to the extent that the remaining net book value of the generating unit exceeds the present value of the amount expected to be recovered from ratepayers. No impairment was recorded as of September 30, 2023.
MGE Energy and MGE reviewed FASB authoritative guidance recently issued, none of which are expected to have a material impact on their consolidated results of operations, financial condition, or cash flows.
ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, a subsidiary of MGE Energy. ATC Holdco was formed by several members of ATC, including MGE Energy, to pursue electric transmission development and investments outside of Wisconsin. The ownership interest in ATC Holdco is held by MGEE Transco, a subsidiary of MGE Energy.
MGE Transco and MGEE Transco have accounted for their investments in ATC and ATC Holdco, respectively, under the equity method of accounting. Equity earnings from investments are recorded as "Other income" on the consolidated statements of income of MGE Energy. MGE Transco recorded the following amounts related to its investment in ATC:
Equity earnings from investment in ATC
2,662
1,473
7,844
6,543
Dividends received from ATC
2,057
2,005
Capital contributions to ATC
1,075
536
3,033
2,319
ATC Holdco was formed in December 2016. ATC Holdco's transmission development activities have been suspended for the near term.
In October 2023, MGE Transco made a $0.7 million capital contribution to ATC.
ATC's summarized financial data is as follows:
Operating revenues
206,197
169,779
610,399
552,383
Operating expenses
(102,819
(97,629
(303,412
(288,376
701
1,657
1,020
(33,555
(34,794
(99,969
(92,293
Earnings before members' income taxes
70,524
37,628
208,675
172,734
MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, 2023, MGE recorded $8.5 million and $25.4 million, respectively, for transmission service compared to $7.9 million and $23.6 million for comparable periods in 2022. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of September 30, 2023, and December 31, 2022, MGE had a receivable due from ATC of $5.3 million and $4.8 million, respectively. The receivable is primarily related to transmission interconnection activities at Badger Hollow and Paris solar generation sites. MGE will be reimbursed for these costs after the new generation assets are placed into service.
Effective Tax Rate.
The consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows:
Three Months Ended September 30,
Statutory federal income tax rate
21.0
%
State income taxes, net of federal benefit
6.2
Amortized investment tax credits
(0.6
(0.7
Credit for electricity from renewable energy
(4.9
(5.2
AFUDC equity, net
(0.9
(0.4
(1.0
Amortization of utility excess deferred tax - tax reform(a)
(1.4
(1.7
(1.5
(1.8
Other, net, individually insignificant
(0.5
(0.1
(0.2
Effective income tax rate
18.9
19.5
18.4
Nine Months Ended September 30,
6.3
(5.4
(5.3
(5.7
(1.6
(1.9
(0.3
18.8
18.2
MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits and defined contribution 401(k) benefit plans for its employees and retirees.
The components of net periodic benefit cost, other than the service cost component, are recorded in "Other income, net" on the consolidated statements of income. The service cost component is recorded in "Other operations and maintenance" on the consolidated statements of income. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net periodic benefit costs are recovered and when costs are recognized.
The following table presents the components of net periodic benefit costs recognized.
Pension Benefits
Components of net periodic benefit cost:
Service cost
723
1,266
2,169
3,798
Interest cost
4,330
2,791
12,989
8,371
Expected return on assets
(6,312
(7,848
(18,936
(23,543
Amortization of:
Prior service credit
(5
(15
Actuarial loss
440
604
1,320
1,812
Net periodic benefit (credit) cost
(819
(3,192
(2,458
(9,577
Postretirement Benefits
195
323
585
970
827
485
2,481
1,455
(649
(842
(1,946
(2,524
Transition obligation
(74
(223
Actuarial (gain) loss
(48
37
(143
109
326
(70
979
(211
As approved by the PSCW, MGE is allowed to defer differences between actual employee benefit plan costs and costs reflected in current rates. The deferred costs may be recovered or refunded in MGE's next rate filing. During the three and nine months ended September 30, 2023, MGE deferred $1.6 million and $2.4 million, respectively, of pension and other postretirement costs. During the three and nine months ended September 30, 2022, MGE recovered $0.2 million and $0.8 million, respectively, of pension and other postretirement costs previously deferred. These costs have not been reflected in the table above.
Shares of MGE Energy common stock are sold through MGE Energy's Direct Stock Purchase and Dividend Reinvestment Plan (the Stock Plan). Those shares may be newly issued shares or shares that are purchased in the open market by an independent agent for participants in the Stock Plan. Sales of newly issued shares under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. During the three and nine months ended September 30, 2023 and 2022, MGE Energy issued no new shares of common stock under the Stock Plan.
As of September 30, 2023, 21,423 shares were included in the calculation of diluted earnings per share related to nonvested equity awards. See Footnote 7 for additional information on share-based compensation awards.
In March 2023, $19.3 million of City of Madison, Wisconsin Industrial Development Revenue Refunding Bonds (Madison Gas and Electric Company Project), Series 2020A were remarketed. As a result of the remarketing, the Series 2020A Bonds will carry an interest rate of 3.75% per annum over its remaining 5-year life. The remarketed Series 2020A Bonds will not be subject to further remarketing or optional redemption prior to their maturity.
In August 2023, MGE entered into a private placement Note Purchase Agreement in which it committed to issue $40 million of new long-term debt (Series A), carrying an interest rate of 5.61% per annum over its 11-year life, and $30 million of new long-term debt (Series B), carrying an interest rate of 5.91% per
annum over its 30-year life. Funding occurred on September 13, 2023, for Series A and funding for Series B is expected to occur on December 1, 2023. The proceeds of the debt financing were used to repay at maturity $30 million long-term debt due September 15, 2023, and will assist with capital expenditures and other corporate obligations. The covenants of this debt are substantially consistent with MGE's existing unsecured senior notes.
During the three and nine months ended September 30, 2023, MGE recorded less than $0.1 million and $1.8 million, respectively, in compensation expense related to share-based compensation awards compared to $0.6 million compensation benefit and $0.1 million in compensation expense for the comparable periods in 2022.
In the first quarter of 2023, cash payments of $3.6 million were distributed related to awards that were granted in 2020 under the 2013 Director Incentive Plan, 2018 under the 2006 Performance Unit Plan, and 2020 under the 2020 Performance Unit Plan.
In March 2023, MGE issued 11,320 performance units and 20,472 restricted stock units under the 2021 Plan to eligible employees and non-employee directors.
MGE recognizes stock-based compensation expense on a straight-line basis over the requisite service period. Awards classified as equity awards are measured based on their grant-date fair value. Awards classified as liability awards are recorded at fair value each reporting period. The performance units can be paid out in either cash, shares of common stock or a combination of cash and stock and are classified as a liability award. The restricted stock units will be paid out in shares of common stock, and therefore are classified as equity awards.
In February 2021, MGE and the other co-owners of Columbia announced plans to retire that facility. The co-owners intend to retire Unit 1 and Unit 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. Effects of the environmental compliance requirements discussed below will depend upon the final retirement dates approved and required compliance dates.
MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which operations are conducted, the costs of operations, as well as capital and operating expenditures. Several of these
environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Regulatory initiatives, proposed rules, and court challenges to adopted rules could have a material effect on capital expenditures and operating costs. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.
These initiatives, proposed rules, and court challenges include:
With the closure of the wet pond system (as described in further detail in the CCR section below), Columbia will be in compliance with ELG requirements.
The Elm Road Units must satisfy the ELG rule's requirements no later than December 2023, as determined by the permitting authority. In December 2021, the PSCW approved a CA application for installation of additional wastewater treatment equipment to comply with the ELG Rule. MGE's share of the costs to comply with the rule is estimated to be approximately $4 million. Construction began in March 2022 and is scheduled to be completed by the end of 2023.
In March 2023, the EPA published a proposed update to this rule that further regulates the wastewater discharges associated with coal-fired power plants. The proposed rule focuses on wastewater discharges from flue gas desulfurization, bottom ash transport water, and combustion residual leachate. The proposed rule includes some flexibility for plants that have already installed pollution controls based on previous versions of the rule, and flexibility for plants that will be retiring or switching to natural gas by certain dates. MGE expects this rule, if finalized as proposed, to impact our Elm Road Units. However, we will not know the impact of this rule with any certainty until the rule is finalized.
Blount received its most recent WPDES permit from the Wisconsin Department of Natural Resources (WDNR) in October 2023. Blount's latest WPDES permit assumes that the plant meets BTA standards for entrainment for the duration of this permit which expires in 2028. The WDNR included a requirement to conduct an impingement study in the latest permit which needs to be completed in the next three years. Once the WDNR determines the impingement requirements at Blount, MGE will be able to determine any compliance costs of meeting Blount's permit requirements.
Intakes at Columbia are subject to this rule. The Columbia operator's most recent permit requires that studies of intake structures be submitted to the WDNR by November 2023 to help determine BTA. Columbia's permit renewal application is due in 2024. BTA improvements may be limited or not required in the renewal permit given the owners' plan to retire both units by June of 2026. MGE will continue to work with Columbia's operator to evaluate regulatory requirements in light of the planned retirements. MGE does not expect this rule to have a material effect on Columbia.
In May 2023, the EPA proposed a rule under section 111 of the Clean Air Act to establish NSPS and emission guidelines to limit GHG emissions from existing fossil fuel-fired EGUs and new, modified, and/or reconstructed fossil fuel-fired power plants. The EPA anticipates promulgating a final rule in
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2024. MGE fossil fuel-fired generation units would be subject to the rule as proposed. MGE expects larger-sized units with long range retirement plans, West Riverside and the Elm Road units, may need to employ technology to achieve reduction. Columbia may not be impacted due to the owners' planned retirement of the existing fossil fuel fired units by 2026. However, we will not know the impact of this rule with any certainty until the rule is finalized.
The Elm Road Units are located in Milwaukee County, Wisconsin, a "moderate" nonattainment area. The deadline for moderate classified areas to meet attainment standards is August 2024. At this time, the operator of the Elm Road Units does not expect that the 2015 Ozone NAAQS will have a material effect on the Units based on final designations.
In January 2023, the EPA published a proposed rule to lower the average annual PM2.5 NAAQS from its current level. The EPA has also solicited comments on whether to lower the annual standard further than the proposed level, and whether to lower the maximum 24-hour limit to be consistent with recommendations from its Clean Air Scientific Advisory Committee (CASAC). Neither the proposed annual PM2.5 NAAQS nor the 24-hour limit recommended by the CASAC are expected to impact the counties where Columbia and the Elm Road Units are located. However, if the annual PM2.5 NAAQS is lowered further than the EPA's currently proposed value, Milwaukee County may be in nonattainment with the standard. A nonattainment designation would require the State of Wisconsin to develop a plan to get into attainment, which may include additional emission limitations for the Elm Road units. However, we will not know the impact of this rule until it is finalized, the EPA determines the attainment status of Wisconsin counties, and the State of Wisconsin develops an attainment implementation plan. MGE will continue to follow the rule's developments.
The EPA's CSAPR and its progeny are a suite of interstate air pollution transport rules designed to reduce ozone and PM2.5 ambient air levels in areas that the EPA has determined as being significantly impacted by pollution from upwind states. This is accomplished through a reduction in NOx and SO2 from qualifying fossil-fuel fired power plants and industrial boilers in upwind "contributing" states. NOx and SO2 contribute to fine particulate pollution and NOx contributes to ozone formation in downwind areas. Reductions are generally achieved through a cap-and-trade system. Individual plants can meet their caps through reducing emissions and/or buying allowances on the market.
In March 2023, the EPA finalized its Federal Implementation Plan (FIP) to address state obligations under the Clean Air Act "good neighbor" provisions for the 2015 Ozone NAAQS. The final rule impacts 23 states, including Wisconsin. For Wisconsin, the rule includes revisions to the current obligations for fossil-fuel power generation, which includes Blount, Columbia, the Elm Road Units, WCCF, West Riverside, and West Marinette. The final rule became effective partway through the 2023 ozone season in August 2023. Emissions budgets can be met with planned retirements, fuel switching, and immediately available measures, including consistently operating emissions controls already installed at power plants. MGE expects to meet the emission reductions with immediately available measures. In 2026, additional obligations would go into effect, including a further reduction in emissions budgets. Wisconsin would need to submit a State Implementation Plan to meet its obligations or accept the EPA's FIP. MGE is reviewing the final rule. Based on our current evaluation, the 2026 additional emission reductions may impact the Elm Road Units and additional upgrades may be needed to comply, however, we will not know the final impact until evaluations are completed.
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The CCR rule regulates the disposal of solid waste coal ash and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation. The CCR rule requires owners or operators of coal-fired power plants to stop transporting CCR and non-CCR wastewater to unlined surface impoundments. In addition, regulated entities must initiate impoundment closure as soon as feasible and in no event later than April 2021, unless the EPA grants an extension. A site-specific extension to initiate closure of the primary ash pond at Columbia by March 31, 2023, was requested, and was met. The EPA has confirmed that Columbia met the required extension requirements, has documented that Columbia ceased the receipt of waste on March 23, 2023, and has noted that Columbia's obligations under this portion of the CCR Rule are now complete.
In July 2021, the PSCW approved a CA application filed by MGE and the other owners of Columbia to install technology required to cease bottom ash transport water discharges rather than extend the longevity of the ash ponds. The coal combustion residuals system that replaced the unlined surface impoundment was placed in-service in March 2023. MGE's share of the costs of the project is approximately $4 million.
Review of the Elm Road Units has indicated that the costs to comply with the CCR rule are not expected to be significant.
In May 2023, the EPA proposed a CCR Legacy Rule that if finalized as currently written, will apply to previously closed CCR sites. Columbia's operator would likely need to complete a site evaluation to determine if the CCR Legacy Rule applies to Columbia's previously closed site. MGE is currently evaluating this proposed rule. However, we will not know the impact of this rule with any certainty until the rule is finalized.
MGE is involved in various legal matters that are being defended and handled in the normal course of business. MGE accrues for costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements. MGE does not expect the resolution of these matters to have a material adverse effect on its consolidated results of operations, financial condition, or cash flows.
Certain environmental groups filed petitions against the PSCW challenging the fixed customer charge set in MGE's 2022/2023 rate settlement and 2023 electric limited reopener. MGE has intervened in the petitions in cooperation with the PSCW. See Footnote 9.a. for more information regarding this matter.
MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. The following table shows future commitments related to purchase contracts as of September 30, 2023:
2024
2025
2026
2027
Thereafter
Coal(a)
8,511
23,173
14,425
2,581
Natural gas(b)
20,009
41,502
25,517
14,873
2,165
11,995
28,520
64,675
39,942
17,454
21
Rate increase
Return on Common Equity
Common Equity Component of Regulatory Capital Structure
Effective Date
Approved 2022/2023 settlement(a)
Electric
8.81%
9.8%
55.6%
1/1/2022
Gas
2.15%
0.96%
1/1/2023
Approved limited 2023 reopener(b)
9.01%
Proposed 2024/2025 rate proceeding(c)
Electric(d)
3.75%
56.1%
1/1/2024
Gas(d)
2.56%
Electric(e)
3.41%
1/1/2025
Gas(e)
1.66%
Sierra Club and Vote Solar have filed petitions with the Dane County Circuit Court seeking review of the PSCW decisions approving MGE's electric and gas 2022/2023 rate settlement and 2023 electric limited reopener. The PSCW is named as the responding party; MGE is not named as a party. The Petitions challenge the amount of customer fixed charge that does not vary with usage. The requested relief is unclear. The revenue requirement approved by the PSCW in the settlement and limited reopener have not been challenged. The PSCW is expected to vigorously defend its approval of the rate case settlement and limited reopener. MGE has intervened in the proceedings to further defend the PSCW's decision. The Dane County Circuit Court affirmed the PSCW's decision to approve the 2022/2023 rate
settlement, and Sierra Club and Vote Solar have now appealed that decision to the Wisconsin Court of Appeals.
Fuel rules require Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over- or under-recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The fuel rules bandwidth is set at plus or minus 2% in 2023 and 1% in 2022. The electric fuel-related costs are subject to an excess revenues test. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The recovery of under-collected electric fuel-related costs would be reduced by the amount that exceeds the excess revenue test. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral. The following table summarizes deferred electric fuel-related costs:
Fuel Costs (in millions)
Refund or Recovery Period
2021 deferred fuel costs
$3.3(a)
January 2023 through December 2023(b)
2022 deferred fuel costs
$8.8(a)
October 2023 through September 2024(c)
2023 deferred fuel savings
($4.3)
(d)
As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, the derivatives are recognized in the consolidated balance sheets at fair value. MGE's financial commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability depending on whether the derivative is in a net loss or net gain position, respectively. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are refundable or recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.
The gross notional volume of open derivatives is as follows:
December 31, 2022
Commodity derivative contracts
384,080
353,600
7,780,000
8,070,000
FTRs
2,901
1,945
MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or
power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds financial transmission rights (FTRs). An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. As of September 30, 2023, and December 31, 2022, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $2.5 million and $5.1 million, respectively.
MGE was a party to a purchased power agreement that provided MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement was accounted for as a derivative contract and was recognized at its fair value on the consolidated balance sheets. However, the derivative qualified for regulatory deferral and was recognized with a corresponding regulatory asset or liability depending on whether the fair value was in a loss or gain position. The actual cost was recognized in purchased power expense in the month of purchase.
The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral.
Derivative
Assets
Liabilities
Balance Sheet Location
Commodity derivative contracts(a)
837
3,424
413
337
2,164
7,687
802
476
103
The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the consolidated balance sheets.
Offsetting of Derivative Assets
Gross Amounts
Gross Amounts Offset in Balance Sheets
Collateral Posted Against Derivative Positions
Net Amount Presented in Balance Sheets
952
(952
2,966
(2,966
24
Offsetting of Derivative Liabilities
3,837
(2,885
8,163
(5,197
The following tables summarize the unrealized and realized gains/losses related to the derivative instruments on the consolidated balance sheets and the consolidated statements of income.
Current and Long-Term Regulatory Asset (Liability)
Other Current Assets
Three Months Ended September 30:
Balance as of July 1,
5,017
1,074
(8,484
(161
Unrealized loss (gain)
1,100
(4,385
Realized (loss) gain reclassified to a deferred account
(1,676
1,676
1,122
(1,122
Realized (loss) gain reclassified to income statement
(1,893
(2,155
6,534
1,916
Balance as of September 30,
2,548
595
(5,213
633
Nine Months Ended September 30:
Balance as of January 1,
5,094
2,747
(617
770
15,495
(21,706
(10,581
10,581
3,952
(3,952
(7,460
(12,733
13,158
3,815
Realized Losses (Gains)
Fuel for Electric Generation/ Purchased Power
Cost of Gas Sold
4,179
(8,698
36
(131
212
14,566
6,451
(14,343
(800
(824
812
(2,642
MGE's commodity derivative contracts, FTRs, and PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheets and are recognized in earnings in the delivery month applicable to the instrument. As a result of the treatment described above, there are no unrealized gains or losses that flow through earnings.
Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of September 30, 2023, and December 31, 2022, no counterparties were in a net liability position.
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Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of September 30, 2023, no counterparties had defaulted.
Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The accounting standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three-level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:
Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.
Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.
Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.
The carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of long-term debt is based on quoted market prices for similar financial instruments. Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market value of financial instruments are as follows:
Carrying Amount
Fair Value
Long-term debt(a)
699,812
606,355
643,560
571,374
The following table presents the balances of assets and liabilities measured at fair value on a recurring basis.
Fair Value as of September 30, 2023
Level 1
Level 2
Level 3
Assets:
Derivatives, net(b)
1,289
766
523
Exchange-traded investments
1,771
3,060
2,537
Liabilities:
2,190
1,647
Deferred compensation
5,077
Total Liabilities
8,914
1,372
849
Fair Value as of December 31, 2022
3,069
1,353
1,716
1,516
4,585
2,869
5,581
2,582
4,743
12,906
3,184
1,468
Exchange-traded Investments. Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.
Deferred Compensation. The deferred compensation plans allow participants to defer certain cash compensation into notional investment accounts. These amounts are included within "Other deferred liabilities and other" in the consolidated balance sheets. The value of certain deferred compensation obligations is based on the market value of the participants' notional investment accounts. The
27
underlying notional investments are comprised primarily of equities, mutual funds, and fixed income securities which are based on directly and indirectly observable market prices. Since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.
The value of legacy deferred compensation obligations are based on notional investments that earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26-week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.
Derivatives. Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange-traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.
The purchased power agreement, with a term ended May 2022, (see Footnote 10) was valued using an internal pricing model and therefore was classified as Level 3. See the 2022 Annual Report on Form 10-K for details on the internal pricing model and significant unobservable inputs.
The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis.
(2,892)
8,959
(866)
178
Realized and unrealized gains (losses):
Included in regulatory assets
1,768
(258)
Included in regulatory liability
(5,105)
3,675
Included in other comprehensive income
Included in earnings
(2,016)
6,609
(7,590)
13,607
Included in current assets
(73)
45
Purchases
108
11,911
Sales
Issuances
Settlements
2,016
(6,644)
7,590
(25,562)
(1,124)
3,854
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held as of September 30,(c)
The following table presents total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis(c).
Purchased power expense
6,644
13,805
Cost of gas sold expense
(35)
(198)
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MGE has ownership interests in generation projects with other co-owners, some of which are under construction, as shown in the following table. Incurred costs are reflected in "Property, plant, and equipment, net" or "Construction work in progress" on the consolidated balance sheets.
Project
Ownership Interest
Source
Share of Generation
Share of Estimated Costs(a)
Costs incurred as of September 30, 2023(a)
Date of Commercial Operation
Red Barn(b)
10%
Wind
9.16 MW
$18 million
$16.5 million
April 2023
Badger Hollow II(c)
33%
Solar
50 MW
$86 million(i)
$58.9 million(f)
Late 2023 or early 2024(g)
Paris(d)
Solar/Battery
20 MW/11 MW
$61 million(i)
$34.5 million
2024(g) Solar2025(g) Battery
Darien(e)
25 MW
$46 million(i)(j)
$21.9 million
2024(g)
3.4%
Natural Gas
$25 million
$24.7 million
(h)
MGE received specific approval to recover 100% AFUDC on Badger Hollow II, Paris, and Darien. During the three and nine months ended September 30, 2023, MGE recognized $1.9 million and $4.8 million, respectively, after tax, in AFUDC for these projects compared to $1.1 million and $2.1 million for the comparable periods in 2022.
Revenues disaggregated by revenue source were as follows:
Residential
50,008
45,154
131,552
123,183
Commercial
70,795
65,468
193,760
177,877
Industrial
3,715
3,912
10,578
10,535
Other-retail/municipal
10,991
10,010
30,853
28,215
Total retail
135,509
124,544
366,743
339,810
Sales to the market
3,305
7,858
9,617
13,938
77
474
1,267
1,167
Total electric revenues
138,891
132,876
377,627
354,915
13,719
17,167
86,131
97,498
Commercial/Industrial
6,016
11,490
55,726
66,913
19,735
28,657
141,857
164,411
Gas transportation
1,587
1,588
5,354
4,804
102
65
466
90
Total gas revenues
Non-regulated energy revenues
213
214
475
Total Operating Revenue
MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See the 2022 Annual Report on Form 10-K for additional discussion of each of these segments.
(In thousands)MGE Energy
Non-Regulated Energy
Transmission Investment
All Others
Consolidation/Elimination
Consolidated Total
Interdepartmental revenues
512
3,547
10,398
(14,457
Total operating revenues
139,403
24,971
10,611
Equity in earnings of investments
2,690
Net income (loss)
31,126
(801
5,627
1,957
(52
12,465
10,405
(22,894
132,900
42,775
10,619
1,499
27,619
(394
5,576
1,091
(172
653
12,978
31,143
(44,774
378,280
160,655
31,618
7,930
65,996
10,539
16,667
5,770
(1,356
76
26,645
31,073
(57,794
354,991
195,950
31,539
6,626
55,248
12,782
16,451
4,821
599
(In thousands)MGE
Net income (loss) attributable to MGE
Net income attributable to MGE
General
MGE Energy is an investor-owned public utility holding company operating through subsidiaries in five business segments:
Our principal subsidiary is MGE, which generates and distributes electric energy, distributes natural gas, and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates, purchases, and distributes electricity to approximately 161,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 173,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.
Our nonregulated energy operations own interests in electric generating capacity that is leased to MGE. The ownership/leasing structure was adopted under applicable state regulatory guidelines for MGE's participation in these generation facilities, consisting principally of a stable return on the equity investment in the new generation facilities over the term of the related leases. The nonregulated energy operations include an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin and a partial ownership of a cogeneration project on the UW-Madison campus. A third party operates the units in Oak Creek, and MGE operates the cogeneration project. Due to the nature of MGE's participation in these facilities, the results of MGE Energy's nonregulated operations are also consolidated into MGE's consolidated financial position and results of operations under applicable accounting standards.
Executive Overview
Our primary focus today and for the foreseeable future is our core utility customers at MGE as well as creating long-term value for our shareholders. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE works on meeting this challenge by investing in more efficient generation projects, including renewable energy sources. As we work toward achieving 80% carbon reduction by 2030 (from 2005 levels), MGE continues to examine and pursue opportunities to reduce the proportion that coal generation represents in its generation mix, as evidenced by its announcements of the retirement of Columbia (a coal generation plant), the planned change in the Elm Road Units fuel source from coal to natural gas, and its growing ownership of renewable generation sources. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE's goal is to provide safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit rating consistent with financial strength in MGE in order to accomplish these goals.
We principally earn revenue and generate cash from operations by providing electric and natural gas utility services, including electric power generation and electric power and gas distribution. The earnings and cash flows from the utility business are sensitive to various external factors, including:
During the three months ended September 30, 2023, MGE Energy's earnings were $37.9 million or $1.05 per share compared to $33.7 million or $0.93 per share during the same period in the prior year. MGE's earnings during the three months ended September 30, 2023, were $30.5 million compared to $27.2 million during the same period in the prior year.
During the nine months ended September 30, 2023, MGE Energy's earnings were $97.6 million or $2.70 per share compared to $89.9 million or $2.49 per share during the same period in the prior year. MGE's earnings during the nine months ended September 30, 2023, were $76.8 million compared to $68.5 million during the same period in the prior year.
MGE Energy's net income was derived from our business segments as follows:
(In millions)
Business Segment:
Electric Utility
31.1
27.6
66.0
55.2
Gas Utility
(0.8)
(0.4)
10.5
12.8
Nonregulated Energy
5.6
16.7
16.5
Transmission Investments
2.0
1.1
5.8
4.8
All Other
(0.2)
(1.4)
0.6
37.9
33.7
97.6
89.9
Our net income during the three and nine months ended September 30, 2023, compared to the same periods in the prior year primarily reflects the effects of the following factors:
An increase in electric investments contributed to earnings for 2023. Timing of depreciation expense and lower fuel costs also contributed to higher earnings in the first nine months of 2023. Depreciation expense is expected to increase after significant capital projects (Badger Hollow II and Paris) are completed. Weather during 2023 has also impacted electric earnings. Warmer than normal weather during the heating season in the first quarter of 2023 lowered electric retail sales reducing earnings and warmer than normal weather in the third quarter of 2023 increased electric retail sales increasing earnings. Electric retail sales decreased approximately 1% during the first nine months of 2023 compared to the same period in the prior year. Electric retail sales increased approximately 1% during the third quarter of 2023 compared to the same period in the prior year.
Lower gas retail sales resulting from warmer than normal weather in the first quarter of 2023 contributed to lower gas earnings for the nine months ended September 30, 2023. Gas retail sales decreased approximately 11%. Heating degree days (a measure for determining the impact of weather during the heating season) decreased by approximately 15% in the first nine months of 2023 compared to the same period in the prior year.
In September 2022, our share of ATC's earnings reflected an estimated possible loss of approximately $0.8 million inclusive of interest and net of tax, related to the August 2022 developments in the MISO transmission owners complaints on authorized return on equity. See additional information in "Other Matters" below.
Investment losses from our venture capital funds resulted in lower earnings in 2023 compared to the same period in the prior year. These venture capital investments support early-stage companies working to advance smart technologies, the customer experience, distributed energy resources, electrification, cybersecurity and other priorities for utility companies such as greater sustainability.
The following developments affected the first nine months of 2023:
2022/2023 Rate Settlement Agreement and 2023 Electric Limited Rate Case Reopener: In December 2021, the PSCW approved a settlement agreement for MGE's 2022 rate case. As part of that settlement agreement, the PSCW approved a 0.96% increase in 2023 gas rates and a 2023 electric rate change to be addressed through a
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limited rate case reopener. In December 2022, the PSCW approved an 9.01% increase to electric rates for 2023. See "Other Matters" below for additional information on the 2022/2023 rate case settlement and 2023 Electric Limited Rate Case reopener.
Utility Solar: Large solar generation projects, some of which are under construction, are shown in the following table. Incurred costs are reflected in "Property, plant, and equipment, net" for projects placed in service, or "Construction work in progress" for projects under construction on the consolidated balance sheets.
Share ofEstimated Costs(a)
Red Barn
$86 million(e)
$58.9 million(b)(c)
Late 2023 or early 2024(d)
$61 million(e)
$34.5 million(b)
2024(d) Solar2025(d) Battery
$46 million(e)(f)
$21.9 million(b)
2024(d)
West Riverside: In March 2023, MGE purchased a 3.4% ownership interest in the natural gas-fired facility West Riverside from WPL, the operator of the plant, for approximately $25 million. MGE's share of the generation capacity of West Riverside is 25 MW.
Deferred Fuel Savings: As of September 30, 2023, MGE has deferred $4.3 million of 2023 fuel savings. These costs will be subject to the PSCW's annual review of 2023 fuel costs, expected to be completed during 2024. See Footnote 9 of the Notes to the Consolidated Financial Statements in this Report for further information regarding fuel cost proceedings.
In the near term, several items may affect us, including:
2022 Annual Fuel Proceeding: MGE under-recovered fuel costs in 2022. As of December 31, 2022, MGE had deferred $8.8 million of 2022 fuel costs. In August 2023, the PSCW issued a final decision in the 2022 fuel rules proceedings for MGE to recover these costs over a 12-month period from October 2023 through September 2024. There was no change to the costs to be recovered in the fuel rule proceedings from the amount MGE deferred in the previous year.
2024/2025 Rate Proceeding: In April 2023, MGE filed with the PSCW a proposed 2024/2025 rate application. MGE has proposed a 3.75% increase for electric rates and a 2.56% increase to gas rates for 2024. The proceeding also proposes a 3.41% increase for electric rates and a 1.66% increase to gas rates for 2025. A final order is expected before the end of 2023. MGE cannot predict with any certainty the final outcome of the rate proceeding. Regulated entities are allowed to defer certain costs that would otherwise be charged to expense if the regulated entity believes the recovery of those costs is probable. Recovery of the deferred costs in future rates is subject to the review and approval by the PSCW. Any disallowance of previously deferred costs would be charged to income in the current period. See "Other Matters" below for additional information on the 2024/2025 rate proceeding.
ATC Return on Equity: As discussed in "Other Matters" below, ATC's authorized ROE, which is used in calculating its rates and revenues, is the subject of a challenge before FERC. A decrease in ATC's ROE could result in lower equity earnings and distributions from ATC in the future. We derived approximately 5.7% and 5.1% of our net income during the nine months ended September 30, 2023 and 2022, respectively, from our investment in ATC.
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Environmental Initiatives: There are proposed legislative rules and initiatives involving matters related to air emissions, water effluent, hazardous materials, and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. Legislation and rulemaking addressing climate change and related matters could significantly affect the costs of owning and operating fossil-fueled generating plants. We would expect to seek and receive recovery of any such costs in rates. However, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of any legislation or rules, and the scope and time of the recovery of costs in rates, which may occur after those costs have been incurred and paid.
Future Generation – 80% carbon reduction target by 2030 (from 2005 levels): MGE has outlined initiatives to achieve our target.
Elm Road Units: MGE, along with the plant co-owners, announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. Transition plans and costs will be subject to PSCW approval. MGE's remaining use of coal is expected to be further reduced as the Elm Road Units transition to natural gas. By the end of 2030, MGE expects coal to be used only as a backup fuel at the Elm Road Units. This transition will help MGE meet its 2030 carbon reduction goals. By 2032, MGE expects that the Elm Road Units will be fully transitioned away from coal, which will eliminate coal as an internal generation source for MGE.
Environmental Initiatives – Natural gas distribution: Building upon our long-standing commitment to providing affordable, sustainable energy, MGE has set a goal to achieve net-zero methane emissions from its natural gas distribution system by 2035. If MGE can accelerate plans to achieve net-zero methane emissions from its natural gas system—through the evolution of new technologies, such as renewable natural gas—it will. MGE is working to reduce overall emissions from its natural gas distribution system cost-effectively as quickly as possible.
Solar Procurement Disruptions: MGE is monitoring import regulations under the Uyghur Forced Labor Protection Act and the U.S. Department of Commerce investigation on whether to impose new solar tariffs. These disruptions have a potential to impact current and future solar projects which may result in an increase in costs or delays in construction timelines. In the event that such disruptions cause costs to exceed the levels approved for specific projects, we have filed and expect to continue to file a notification with the PSCW and expect to request recovery of any increases in MGE's future rate proceedings. See "Other Matters" below for additional information on the solar procurement disruptions.
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The following discussion is based on the business segments as discussed in Footnote 14 of the Notes to Consolidated Financial Statements in this Report.
Results of Operations
Three Months Ended September 30, 2023 and 2022
Electric sales and revenues
The following table compares MGE's electric revenues and electric kWh sales by customer class for each of the periods indicated:
Revenues
Sales (kWh)
(In thousands, except CDD)
% Change
10.7%
264,678
252,457
4.8%
8.1%
496,161
495,135
0.2%
(5.0)%
39,908
41,304
(3.4)%
102,400
104,548
(2.1)%
8.8%
903,147
893,444
1.1%
(57.9)%
72,916
48,632
49.9%
(83.8)%
—%
4.5%
976,063
942,076
3.6%
Cooling degree days (normal 502)
549
507
8.3%
Electric revenue increased $6.0 million during the three months ended September 30, 2023, compared to the same period in the prior year, due to the following:
Rate changes
12.3
Increase in residential volume
1.8
(4.5
Revenue subject to refund, net
(2.9
Customer fixed and demand charges
6.0
35
Electric fuel and purchased power
$ Change
19.7
(1.3)
7.0
9.6
(2.6)
The $1.3 million decrease in fuel for electric generation was due to an approximately 18% decrease in the average cost offset by an approximately 15% increase in internal generation. Columbia generation was higher during the three months ended September 30, 2023, compared to the same period in the prior year as a result of market prices.
The $2.6 million decrease in purchased power was due to an approximately 40% decrease in market purchases as a result of higher internal generation, partially offset by an approximately 4% increase in average cost.
Fuel and purchased power costs are generally offset by electric revenue and do not have a significant impact on net income. MGE expects to seek and receive recovery of fuel and purchased power costs that exceed the fuel rules bandwidth in customer rates. See Footnote 9 of the Notes to Consolidated Financial Statements in this Report for further information on the fuel rules bandwidth.
Gas deliveries and revenues
The following table compares MGE's gas revenues and gas therms delivered by customer class for each of the periods indicated:
Therms Delivered
(In thousands, except HDD and average
rate per therm of retail customer)
(20.1)%
6,202
6,166
0.6%
(47.6)%
9,335
9,555
(2.3)%
(31.1)%
15,537
15,721
(1.2)%
(0.1)%
15,014
15,183
(1.1)%
56.9%
(29.3)%
30,551
30,904
Heating degree days (normal 138)
70
135
(48.1)%
Average rate per therm of retail customer
1.270
1.823
(30.3)%
Gas revenue decreased $8.9 million during the three months ended September 30, 2023, compared to the same period in the prior year, due to the following:
(8.5
Decrease in volume
0.3
(8.9
MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas. Changes in PGA recoveries affect revenues but do not change net income in view of the pass-through treatment of the costs. Payments for natural gas decreased driving lower rates during the three months ended September 30, 2023.
The average retail rate per therm for the three months ended September 30, 2023, decreased approximately 30% compared to the same period in the prior year, reflecting a decrease in natural gas commodity costs (recovered through the PGA).
Cost of gas sold decreased $9.4 million during the three months ended September 30, 2023, compared to the same period in the prior year. Average cost per therm decreased approximately 64% and therms delivered decreased approximately 2%. MGE recovers the cost of natural gas in its gas segment through the PGA as described under gas deliveries and revenue above.
Consolidated operations and maintenance expenses
During the three months ended September 30, 2023, operations and maintenance expenses increased $4.8 million, compared to the same period in the prior year. The following contributed to the net change:
Increased administrative and general costs
4.1
Increased electric distribution expenses
Increased electric production expenses
Increased other expenses
0.2
Decreased customer accounts costs
Consolidated depreciation expense
Electric depreciation expense increased $3.7 million and gas depreciation expense increased $0.1 million during the three months ended September 30, 2023, compared to the same period in the prior year. As part of the PSCW approved electric limited reopener for 2023, MGE accelerated the depreciation schedule for Columbia Unit 2 from 2038 to 2029 to align with the depreciation schedule previously approved for Columbia Unit 1. The accelerated depreciation schedule, which began in 2023, for Columbia Unit 2 contributed to the increase in electric depreciation expense.
Nonregulated Energy Operations - MGE Energy and MGE
The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF), which have been formed to own and lease electric generating capacity to assist MGE. During both the three months ended September 30, 2023 and 2022, net income at the nonregulated energy operations segment was $5.6 million.
Transmission Investment Operations - MGE Energy
The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was formed in December 2016 to pursue transmission development opportunities that typically have long development and investment lead times before becoming operational. ATC Holdco's transmission development activities have been suspended for the near term. During the three months ended September 30, 2023 and 2022, other income at the transmission investment segment primarily reflects ATC's operations and was $2.7 million and $1.5 million, respectively. See Footnote 3 of the Notes to Consolidated Financial Statements in this Report for summarized financial information regarding ATC and "Other Matters" below for additional information concerning ATC.
Consolidated Income Taxes - MGE Energy and MGE
See Footnote 4 of the Notes to Consolidated Financial Statements in this Report for the effective tax rate reconciliation.
Noncontrolling Interest, Net of Tax - MGE
Noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus. They are not owned by MGE. Due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:
3.7
3.8
Nine Months Ended September 30, 2023 and 2022
6.8%
672,760
679,308
(1.0)%
8.9%
1,356,286
1,368,060
(0.9)%
0.4%
114,514
120,827
(5.2)%
9.3%
274,875
276,843
(0.7)%
7.9%
2,418,435
2,445,038
(31.0)%
126,739
121,848
4.0%
Other revenues
8.6%
6.4%
2,545,174
2,566,886
(0.8)%
Cooling degree days (normal 696)
754
784
(3.8)%
Electric revenue increased $22.7 million during the nine months ended September 30, 2023, compared to the same period in the prior year, due to the following:
32.6
0.1
(4.3
(2.7
Net decrease in commercial, industrial and other-retail/municipal volume
Decrease in residential volume
22.7
38
47.1
48.4
28.3
35.8
(7.5)
The $1.3 million decrease in fuel for electric generation was due to an approximately 8% decrease in the average cost offset by an approximately 6% increase in internal generation. West Riverside was purchased in March 2023 contributing to the increase in internal generation during the nine months ended September 30, 2023, compared to the same period in the prior year.
The $7.5 million decrease in purchased power was due to an approximately 21% decrease in market purchases as a result of lower customer sales and increased internal generation. An approximately 19% decrease in average cost also contributed to the decrease in purchase power costs.
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(11.7)%
66,948
77,091
(13.2)%
(16.7)%
66,584
73,349
(9.2)%
(13.7)%
133,532
150,440
(11.2)%
11.4%
53,319
58,059
(8.2)%
n.m.%
(12.8)%
186,851
208,499
(10.4)%
Heating degree days (normal 4,503)
3,999
4,723
(15.3)%
1.062
1.093
(2.8)%
n.m. not meaningful
Gas revenue decreased $21.6 million during the nine months ended September 30, 2023, compared to the same period in the prior year, due to the following:
(12.4
(10.4
1.2
(21.6
MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas. Changes in PGA recoveries affect revenues but do not change net income in view of the pass-through treatment of the costs. Payments for natural gas decreased driving lower rates during the nine months ended September 30, 2023.
The average retail rate per therm excluding customer fixed charge for the nine months ended September 30, 2023, decreased approximately 3% compared to the same period in the prior year, reflecting a decrease in natural gas commodity costs (recovered through the PGA).
Cost of gas sold decreased $20.3 million during the nine months ended September 30, 2023, compared to the same period in the same period in the prior year. Therms delivered decreased approximately 12% and cost per
40
therm decreased approximately 9%. MGE recovers the cost of natural gas in its gas segment through the PGA as described under gas deliveries and revenue above.
During the nine months ended September 30, 2023, operations and maintenance expenses increased $5.3 million, compared to the same period in the prior year. The following contributed to the net change:
4.7
1.5
Increased customer services
Decreased electric distribution expenses
5.3
Electric depreciation expense increased $10.9 million and gas depreciation expense increased $0.3 million during the nine months ended September 30, 2023, compared to the same period in the prior year. As part of the PSCW approved electric limited reopener for 2023, MGE accelerated the depreciation schedule for Columbia Unit 2 from 2038 to 2029 to align with the depreciation schedule previously approved for Columbia Unit 1. The accelerated depreciation schedule, which began in 2023, for Columbia Unit 2 contributed to the increase in electric depreciation expense.
The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF), which have been formed to own and lease electric generating capacity to assist MGE. During the nine months ended September 30, 2023 and 2022, net income at the nonregulated energy operations segment was $16.7 million and $16.5 million, respectively.
The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was formed in December 2016 to pursue transmission development opportunities that typically have long development and investment lead times before becoming operational. ATC Holdco's transmission development activities have been suspended for the near term. During the nine months ended September 30, 2023 and 2022, other income at the transmission investment segment primarily reflects ATC's operations and was $7.9 million and $6.6 million, respectively. See Footnote 3 of the Notes to Consolidated Financial Statements in this Report for summarized financial information regarding ATC and "Other Matters" below for additional information concerning ATC.
All Other Operations - MGE Energy
Other income
The decrease of $2.7 million in other income from all other operations during the nine months ended September 30, 2023, primarily results from increased investment losses from our venture capital funds compared
41
to the same period in the prior year. These venture capital investments support early-stage companies working to advance smart technologies, the customer experience, distributed energy resources, electrification, cybersecurity and other priorities for utility companies such as greater sustainability.
11.0
5.4
Contractual Obligations and Commercial Commitments - MGE Energy and MGE
There were no material changes, other than from the normal course of business, to MGE Energy's and MGE's contractual obligations (representing cash obligations that are considered to be firm commitments) and commercial commitments (representing commitments triggered by future events) during the nine months ended September 30, 2023, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 16 of the Notes to Consolidated Financial Statements and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in the 2022 Annual Report on Form 10-K.
Purchase Contracts – MGE Energy and MGE
See Footnote 8.c. of Notes to Consolidated Financial Statements in this Report for a description of commitments as of September 30, 2023, that MGE Energy and MGE have entered with respect to various commodity supply and transportation contracts to meet their obligations to deliver electricity and natural gas to customers.
Long-term Debt – MGE Energy and MGE
In March 2023, $19.3 million of City of Madison, Wisconsin Industrial Development Revenue Refunding Bonds, Series 2020A were remarketed. In August 2023, MGE entered into a private placement Note Purchase Agreement in which it committed to issue $70 million of new long-term debt. See Footnote 6.c. of Notes to Consolidated Financial Statements in this Report for further information.
Liquidity and Capital Resources
MGE Energy and MGE expect to have adequate liquidity to support future operations and capital expenditures over the next twelve months. Available resources include cash and cash equivalents, operating cash flows, liquid assets, borrowing capacity under revolving credit facilities, and access to equity and debt capital markets. MGE Energy expects to generate funds from operations and both long-term and short-term debt financing. See "Credit Facilities" under Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources in the 2022 Annual Report on Form 10-K for information regarding MGE Energy's and MGE's credit facilities.
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Cash Flows
The following summarizes cash flows for MGE Energy and MGE during the nine months ended September 30, 2023 and 2022:
Cash provided by (used for):
Operating activities
Investing activities
(156,490)
(137,219)
(151,636)
(134,089)
Financing activities
(39,309)
(12,663)
(41,626)
(8,400)
Cash flows from operating activities for MGE Energy and MGE principally reflect the receipt of customer payments for electric and gas service and outflows related to fuel for electric generation, purchased power, gas, and operation and maintenance expenditures.
MGE Energy's consolidated net cash provided by operating activities is derived mainly from the electric and gas operations of its principal subsidiary, MGE.
Cash provided by operating activities during the nine months ended September 30, 2023, was $194.0 million, an increase of $49.8 million when compared to the same period in the prior year, driven by:
These increases in net cash provided by operating activities were partially offset by:
Cash provided by operating activities during the nine months ended September 30, 2023, was $190.4 million, an increase of $48.6 million when compared to the same period in the prior year, driven by:
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Capital Requirements and Investing Activities
MGE Energy's cash used for investing activities increased $19.3 million during the nine months ended September 30, 2023, when compared to the same period in the prior year.
Capital expenditures during the nine months ended September 30, 2023, were $150.3 million. This amount represents an increase of $16.9 million from the expenditures made in the same period in the prior year. This increase primarily reflects the purchase of 25 MW of West Riverside and purchase of Red Barn wind farm.
Capital contributions in ATC and other investments increased $2.0 million during the nine months ended September 30, 2023, when compared to the same period in the prior year.
MGE's cash used for investing activities increased $17.5 million during the nine months ended September 30, 2023, when compared to the same period in the prior year.
Capital Expenditures
The following table shows MGE Energy's forecasted capital expenditures for 2023 through 2028:
Forecasted
2023(a)
2028
173,000
177,000
186,000
193,000
222,000
207,000
33,000
28,000
29,000
32,000
Utility plant total
206,000
205,000
215,000
225,000
251,000
235,000
Nonregulated
6,000
9,000
10,000
7,000
8,000
MGE Energy total
212,000
214,000
232,000
257,000
243,000
Forecasted capital expenditures are based upon management's assumptions with respect to future events, including the timing and amount of expenditures associated with environmental compliance initiatives, legislative and regulatory action, supply chain and market disruptions, customer demand and support for electrification and renewable energy resources, energy conservation programs, load growth, the timing of any required regulatory approvals, and the adequacy of rate recovery. Actual events may differ materially from these assumptions and result in material changes to those forecasted amounts.
MGE is targeting at least 80% carbon reduction from electric generation by 2030 (from 2005 levels) and net-zero carbon electricity by 2050. Solar, wind, and battery storage projects are a major step toward deep decarbonization and greater use of clean energy sources in pursuit of our goal. MGE continues to evaluate solar, wind, and battery storage projects that align with its goals as legacy fossil fuel-fired facilities are retired. The target early retirement
44
date for Columbia is June 2026. MGE has included forecasted capital expenditures for the years 2023 through 2026 for projects to replace Columbia's generation.
The following table provides further detail of MGE Energy's forecasted capital expenditures, separating spending into capital project categories for 2024 through 2028:
For the years ended December 31,
Electric renewables(a)
76,000
102,000
114,000
146,000
132,000
Electric production
42,000
21,000
20,000
13,000
Electric distribution
59,000
63,000
62,000
Gas distribution
Our forecasted capital expenditures reflect the following significant renewable projects that are completed or currently under construction:
Share ofGeneration/Battery Storage
Share ofEstimatedCosts(b)
Date ofCommercial Operation
Red Barn(a)
9.16MW
$18 million(d)
Badger Hollow II(a)
$86 million(c)(d)
Late 2023 or early 2024(f)
Paris(a)
$61 million(c)(d)
2024(f) Solar2025(f) Battery
Darien(a)
$46 million(c)(d)(e)
2024(f)
Koshkonong(a)
30 MW
$54 million(c)(e)
2026(f)
In 2023, MGE notified the PSCW of increases in projected costs at Badger Hollow II, Paris, and Darien. The main drivers were increases in the costs of key commodities, labor, and solar modules resulting from supply chain and market disruptions. See Footnote 12 of Notes to Consolidated Financial Statements in this Report for more information on these projects. Furthermore, solar procurement disruptions have also shifted construction timelines. MGE continues to assess the potential impact of these disruptions on current and future solar projects that may result in an increase in costs or delays in construction timelines. See further information on procurement disruptions discussed under "Other Matters" section below.
West Riverside: In March 2023, MGE purchased 25 MW of capacity of West Riverside. In September 2023, MGE, along with joint applicants, filed an application with the PSCW requesting approval for a sale and purchase of additional ownership interests in West Riverside. If approved, MGE's share of West Riverside will increase 25 MW at a purchase price of approximately $25 million. The closing and actual transfer of ownership is expected to occur in June 2024.
Electric and Gas Distribution: In 2023 through 2028, electric and gas capital expenditures include investment in enhanced metering solutions to provide customers with more timely and detailed energy use information. Investments in advanced metering infrastructure will provide additional benefits including outage and demand
response and automated meter reading capabilities. Forecasted total capital expenditures for those years is approximately $47 million.
Cash used for MGE Energy's financing activities was $39.3 million during the nine months ended September 30, 2023, compared to $12.7 million for the same period in the prior year.
During the nine months ended September 30, 2023, dividends paid were $44.9 million compared to $42.8 million in the prior year. The increase reflected a higher dividend rate per share ($1.243 vs. $1.183).
During the nine months ended September 30, 2023, MGE issued $90 million of senior unsecured notes which were used to repay $30 million of maturing unsecured senior notes and to assist with financing additional capital expenditures and other corporate obligations. In addition, $19.3 million of Industrial Development Revenue Bonds were tendered by their holders as required by the terms of the bonds and remarketed as permitted by those terms. There were no long-term debt borrowings during the nine months ended September 30, 2022.
During the nine months ended September 30, 2023, net short-term debt repayments were $48.5 million, compared to $34.5 million of borrowings in the same period in the prior year.
During the nine months ended September 30, 2023, cash used for MGE's financing activities was $41.6 million, compared to $8.4 million for the same period in the prior year.
During the nine months ended September 30, 2023, cash dividends to parent (MGE Energy) were $30.0 million, compared to $21.0 million in the same period in the prior year.
Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus to MGE Energy, were $17.3 million during the nine months ended September 30, 2023, compared to $17.5 million in the same period in the prior year.
Capitalization Ratios
MGE Energy's capitalization ratios were as follows:
61.3%
60.4%
37.5%
35.7%
1.2%
3.9%
46
Credit Ratings
MGE Energy's and MGE's access to the capital markets, including, in the case of MGE, the commercial paper market, and their respective financing costs in those markets, may depend on the credit ratings of the entity that is accessing the capital markets.
None of MGE Energy's or MGE's borrowing is subject to default or prepayment as a result of a downgrading of credit ratings, although a downgrading of MGE's credit ratings would increase fees and interest charges under both MGE Energy's and MGE's credit agreements.
Environmental Matters
See the discussion of environmental matters included in the 2022 Annual Report on Form 10-K, as updated by Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.
Other Matters
Rate Matters
In December 2021, the PSCW approved a settlement agreement to increase gas rates 0.96% in 2023 and a potential 2023 electric rate change to be addressed through a limited reopener.
In December 2022, the PSCW approved the 2023 electric rate case limited reopener. The reopener provides for a 9.01% increase to electric rates for 2023.
In April 2023, MGE filed a 2024/2025 rate application with a proposed increase of 3.75% for electric rates and a 2.56% increase for gas rates in 2024. The application also proposes a 3.41% increase for electric rates and a 1.66% increase to gas rates for 2025. PSCW approval is pending. A final order is expected before the end of 2023.
Details related to MGE's 2023 approved settlement agreement and 2023 electric limited reopener, and 2024/2025 proposed rate proceeding are as follows:
(Dollars in thousands)
Authorized Average Rate Base(a)
Authorized Average CWIP(b)
Authorized Return on Common Equity(c)
Electric (2023 Test Period)
1,162,516
19,976
55.63%
Gas (2023 Test Period)
312,270
8,228
Electric (2024 Test Period)(d)
1,202,123
13,995
56.12%
Gas (2024 Test Period)(d)
338,417
3,701
Electric (2025 Test Period)(d)
1,281,236
13,871
56.05%
Gas (2025 Test Period)(d)
345,463
3,341
See Footnote 9 of Notes to Consolidated Financial Statements in this Report for further discussion of rate proceedings.
47
MISO transmission owners, including ATC, are involved in two complaints filed at FERC by several parties challenging the base ROE in effect for MISO transmission owners, including ATC, as being no longer just and reasonable. Each complaint provided for a 15-month statutory refund period: November 12, 2013 through February 11, 2015 (the "First Complaint Period") and February 12, 2015 through May 11, 2016 (the "Second Complaint Period").
In May 2020, FERC issued an order further refining the methodology for setting authorized ROE. This refined methodology increased the authorized ROE from 9.88% to 10.02%. This base ROE is effective for the First Complaint Period and for all periods following September 2016. This order also dismissed the second complaint. Accordingly, no refunds were ordered for the Second Complaint Period.
As a result of the May 2020 FERC order, our share of ATC's earnings reflected a $0.6 million reduction of our reserve. Additionally, our share of ATC's earnings reflected the derecognition of a possible refund related to the Second Complaint Period as ATC considered such a refund to be no longer probable. However, due to pending requests for rehearing, a loss related to the 2015 complaint remains possible. Our share of the estimated refund for the Second Complaint Period is approximately $2.3 million. MGE has not recorded a possible loss for the Second Complaint Period.
Several petitions for review of FERC’s prior orders were filed with the U.S. Court of Appeals for the D.C. Circuit (Court) and an oral argument was held in November 2021. In August 2022, the Court ruled that four of the five arguments made by the complaining parties were unpersuasive. However, the Court agreed that FERC’s decision to reintroduce a risk-premium model into its ROE methodology was arbitrary and capricious. The Court vacated the underlying orders for the First Complaint Period and remanded to FERC for further proceedings. In 2022, our share of ATC's earnings reflected an estimated possible loss of approximately $0.9 million, inclusive of interest and net of tax, for a possible additional refund for the First Complaint Period and for the period following the Second Complaint Period. Although the Court agreed that FERC was correct to use the base ROE established in the first complaint to adjudicate the second, and that FERC was right to dismiss the second complaint, the second complaint was also remanded for FERC to reopen proceedings. Any reduction in ATC's ROE could result in lower equity earnings and distributions from ATC in the future.
We derived approximately 5.7% and 5.1% of our net income during the nine months ended September 30, 2023 and 2022, respectively, from our investment in ATC.
In June 2021, the U.S. Customs and Border Protection (CBP) issued a Withhold Release Order (WRO) against silica-based products made by Hoshine Silicon Industry Co. Ltd., a company located in China's Xinjiang Uyghur Autonomous Region. As a result of this WRO, CBP is holding many solar panels imported into the United States until importers can prove that the panels do not contain materials originating from this region. The Uyghur Forced Labor Protection Act (UFLPA), a federal law that became effective on June 21, 2022, further established that all goods mined, produced, or manufactured wholly or in part in Xinjiang or by certain defined entities are prohibited from U.S. importation. Suppliers for MGE's current solar projects were able to provide the CBP sufficient documentation to meet WRO compliance requirements, and MGE expects the same will be true for UFLPA purposes, however we cannot currently predict what, if any, impact the UFLPA will have on the overall supply of solar panels into the United States and the related impact to timing and cost of solar projects included in our capital plan. In the event that such disruptions cause costs to exceed the levels approved for specific projects, we have filed and expect to continue to file a notification with the PSCW and expect to request recovery of any increases in MGE's future rate proceedings.U.S. Department of Commerce Investigation
In March 2022, the U.S. Department of Commerce (USDOC) announced a solar tariff investigation on solar panels from four Southeast Asian countries. This investigation could result in additional tariffs on solar panels. In June 2022, the USDOC issued a 24-month exemption from tariffs for solar panel and module imports from these four
48
countries. MGE is currently assessing the potential impact of these disruptions on current and future solar projects which may result in an increase in costs or delays in construction timelines. In the event that such disruptions cause costs to exceed the levels approved for specific projects, we have filed and expect to continue to file a notification with the PSCW and expect to request recovery of any increases in MGE's future rate proceedings.
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements
See Footnote 2 of Notes to Consolidated Financial Statements in this Report for discussion of new accounting pronouncements.
49
There were no material changes to the market risks disclosed in Item 7A. Quantitative and Qualitative Disclosures About Market Risk in our 2022 Annual Report on Form 10-K.
During the third quarter of 2023, each registrant's management, including the principal executive officer and principal financial officer, evaluated its disclosure controls and procedures related to the recording, processing, summarization, and reporting of information in its periodic reports that it files with the SEC. These disclosure controls and procedures have been designed to ensure that material information relating to that registrant, including its subsidiaries, is accumulated and made known to that registrant's management, including these officers, by other employees of that registrant and its subsidiaries as appropriate to allow timely decisions regarding required disclosure, and that this information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC's rules and forms. The evaluations take into account changes in the internal and external operating environments that may impact those controls and procedures. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision making can be faulty and breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. Also, MGE Energy does not control or manage certain of its unconsolidated entities and thus, its access and ability to apply its procedures to those entities is more limited than is the case for its consolidated subsidiaries.
As of September 30, 2023, each registrant's principal executive officer and principal financial officer concluded that its disclosure controls and procedures were effective. Each registrant intends to strive continually to improve its disclosure controls and procedures to enhance the quality of its financial reporting.
During the quarter ended September 30, 2023, there were no changes in either registrant's internal controls over financial reporting that materially affected, or are reasonably likely to affect materially, that registrant's internal control over financial reporting.
MGE Energy and its subsidiaries, including MGE, from time to time are involved in various legal proceedings that are handled and defended in the ordinary course of business. See Footnote 8.a. and 8.b. of Notes to Consolidated Financial Statements in this Report for more information.
Item 1A Risk Factors.
There were no material changes from the risk factors disclosed in Item 1A. Risk Factors in our 2022 Annual Report on Form 10-K.
Under the MGE Energy, Inc. Direct Stock Purchase and Dividend Reinvestment Plan (Stock Plan), common stock shares purchased by plan participants may be either shares issued by MGE Energy or shares purchased on the open market, as determined from time to time by MGE Energy. Shares issued by MGE Energy are covered by an existing registration statement. Shares purchased in the open market are purchased at the direction of the plan participants by MGE Energy's transfer agent's securities broker-dealer for the accounts of those plan participants. Subject to the plan's restrictions, the timing and amount of open market purchases is determined by the plan participants and the broker-dealer. MGE Energy is not involved in the open market purchases. During 2023, shares purchased under the Stock Plan have been purchased in the open market.
None.
Not applicable to MGE Energy and MGE.
During the three months ended September 30, 2023, no director or officer of MGEE Energy or Madison Gas and Electric adopted or terminated a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement, as defined in Item 408(a) of Regulation S-K.
Ex. No.
Exhibit Description
*
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for MGE Energy, Inc.
31.2
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jared J. Bushek for MGE Energy, Inc.
31.3
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for Madison Gas and Electric Company
31.4
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jared J. Bushek for Madison Gas and Electric Company
32.1
**
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey M. Keebler for MGE Energy, Inc.
32.2
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jared J. Bushek for MGE Energy, Inc.
32.3
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey M. Keebler for Madison Gas and Electric Company
32.4
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jared J. Bushek for Madison Gas and Electric Company
101.INS
XBRL Instance
101.SCH
XBRL Taxonomy Extension Schema
101.CAL
XBRL Taxonomy Extension Calculation
101.DEF
XBRL Taxonomy Extension Definition
101.LAB
XBRL Taxonomy Extension Labels
101.PRE
XBRL Taxonomy Extension Presentation
104.1
Included in the cover page, formatted in Inline XBRL
Filed herewith.
Furnished herewith.
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
MGE ENERGY, INC.
Date: November 2, 2023
/s/ Jeffrey M. Keebler
Jeffrey M. Keebler
Chairman, President and Chief Executive Officer
(Duly Authorized Officer)
/s/ Jared J. Bushek
Jared J. Bushek
Vice President - Chief Financial Officer and Treasurer
(Chief Financial Officer)
/s/ Tamara J. Johnson
Tamara J. Johnson
Vice President - Chief Accounting Officer and Controller
(Chief Accounting Officer)
Signatures – Madison Gas and Electric Company
MADISON GAS AND ELECTRIC